Wellbore communication system

ABSTRACT

A gap collar for an electromagnetic communication unit of a downhole tool positioned in a wellbore is provided. The downhole tool communicates with a surface unit via an electromagnetic field generated by the electromagnetic communication unit. The gap collar includes a first collar having a first end connector and a second collar having a second end connector matingly connectable to the first end connector. The gap collar further includes a non-conductive insulation coating disposed on the first and/or second end connectors, and a non-conductive insulation molding positioned about an inner and/or outer surface of the collars. The insulation molding moldingly conforms to the shape collars. The connectors are provided with mated threads modified to receive the insulation coating. Measurements taken by the downhole tool may be stored in memory, and transmitted to the surface unit via the electromagnetic field.

Pursuant to 35 U.S.C. § 120, this application is a division of andclaims the benefit of the filing date of U.S. patent application Ser.No. 10/707,970, which was filed on Jan. 29, 2004, now U.S. Pat. No.7,080,699 and is assigned to the assignee of the present application.

BACKGROUND OF THE INVENTION

The present invention relates to the exploration/production of asubterranean formation penetrated by a wellbore. More particularly, thepresent invention relates to techniques for communicating betweenequipment at the surface, and a downhole tool positioned in thewellbore.

The exploration and production of hydrocarbons involves placement of adownhole tool into the wellbore to perform various downhole operations.There are many types of downhole tools used in hydrocarbon reservoirexploration/production. Typically, a drilling tool is suspended from anoil rig and advanced into the earth to form the wellbore. The drillingtool may be a measurement-while-drilling (MWD) or alogging-while-drilling (LWD) tool adapted to perform downholeoperations, such as taking measurements, during the drilling process.Such measurements are generally taken by instruments mounted withindrill collars above the drill bit and may obtain information, such asthe position of the drill bit, the nature of the drilling process,oil/gas composition/quality, pressure, temperature and other geophysicaland geological conditions.

In some instances, it may be desirable to obtain additional data fromthe wellbore after drilling is complete. In such cases, the downholedrilling tool may be removed, and a separate downhole evaluation tool,such as a wireline, slickline, drill stem test or coiled tubing tool,may be lowered into the wellbore to perform additional testing, samplingand/or measuring. Downhole evaluation tools may be lowered into thewellbore via a conveyor, such as wired cable, drill pipe, slickline orcoiled tubing. The evaluation tool may be withdrawn by its conveyor, ordetached and left in the wellbore for later retrieval. Downhole drillingand/or measurement tools may be provided with communication systemsadapted to send signals, such as commands, power and information,between a downhole unit housed in the downhole tool, and a surface unit.Communication systems in drilling tools may include, for example, mudpulse systems that manipulate the flow of drilling mud through adownhole drilling tool to create pressure pulses. One such mud pulsesystem is disclosed in U.S. Pat. No. 5,517,464 and assigned to theassignee of the present invention.

Communication systems in evaluation tools are typically incorporatedinto the conveyor itself, for example via wireline cable, wired drillpipe or wired coiled tubing. In such cases, wiring is usually providedin the conveyor to transmit signals between the surface and the downholetool. The conveyor is often a wireline or armored set of insulatedelectrical cables which provides power to the tool, and controls theoperation of the tool. The conveyor is often used to provide a wiredcommunications link for the telemetry of signals between a surfacecontrol system (such as a computer) and the downhole tool. The tensilestrength of the wireline cable may be a limit to the weight of thedownhole tool and/or the physical and mechanical severity of theborehole conditions in which a downhole tool can be deployed.

In some instances, the communication system is unavailable, inactive ordetached, such as during memory mode logging. In such situations, datais collected and stored in a memory unit within the downhole tool forlater retrieval. By way of example, some wireline tools are deployedinto the wellbore without the wireline connection between the surfacesystem and the downhole tool. The use of a wireline can be too risky touse, or too costly to justify the expense. In such a case, the wirelinecable is detached and the logging tool operates using self-containedpower supplies (usually batteries) and data memory units (data memoryand circuitry to bus the data from the sensors). Such a tool is placedin operation at the surface, then lowered into the wellbore by aconveyor, or dropped or pumped down the wellbore. The tool may be movedpast multiple depth intervals, or it may be left at a single depth inthe well. Regardless, the tool will record well data and store the datain memory for collection by the operator at some future time, such aswhen the tool is returned to the surface. During this type of ‘memorymode’ logging, the operator typically has no communication with the toolto ensure that the tool is working properly throughout the operation, toturn the tool off and on, to change the type of data collected by thetool, or to change the frequency at which the data is collected.

The data collected during memory mode logging is typically retrieved byestablishing (or re-establishing) a wired or mud pulse communicationlink between the downhole tool and the surface, or by retrieving thetool to the surface and downloading the information from the memoryunit. While such techniques provide ways to capture downhole data storedin a downhole tool, there remains a need for techniques which facilitatethe transmission of such data to the surface. It is desirable that suchtechniques utilize wireless technology to transfer the data. It isfurther desirable that a system be provided that is capable of providinga wireless telemetry link, while also providing many of the benefits ofa wireline cable.

Wireless communication techniques, such electromagnetic (or emag)telemetry systems, have been employed in downhole drilling tools. Suchsystems include a downhole unit that creates an electromagnetic fieldcapable of sending a signal to a remote surface unit. Examples ofelectromagnetic telemetry system are disclosed in U.S. Pat. Nos.5,642,051 and 5,396,232, both of which are assigned to the assignee ofthe present invention. Current electromagnetic telemetry systems havebeen used in conventional MWD type drilling operations. It would bedesirable to develop an electromagnetic telemetry system for evaluationtools.

Advancements, such as the use of repeaters and gaps, have beenimplemented in existing drilling tools to improve the operability ofelectromagnetic systems in drilling applications. By creating a gap, ornon-conductive insert, between adjoining sections of drillpipe, theelectromagnetic field is magnified and provides an improved signal.Examples of a gap used in an electromagnetic telemetry system aredescribed in U.S. Pat. No. 5,396,232, assigned to the assignee of thepresent invention and U.S. Pat. No. 2,400,170 assigned to Silverman.

Electromagnetic telemetry systems incorporating gaps have beenvulnerable to the leakage of drilling fluids into the circuitry mountedin drilling tools, resulting in failure of the electromagnetic telemetrysystem. Wellbore fluids tend to leak into the gap and between adjacentdrill collars as well as into the electromagnetic circuitry housed inthe drill collar. In an attempt to reduce such leakage, attempts havebeen made to install insulation into and between drill collars. Someexamples of patents employing insulation in an electromagnetic systeminclude U.S. Pat. No. 5,138,313 to Barrington, PCT Application No.03/004826 to Frasier et al. and U.S. Pat. No. 4,348,672 to Givier. U.S.Pat. Nos. 6,098,727 and 6,493,324 to Ringgenberg et al. describeadditional insulation technique involving coating threads of adjacentdrill collars to create an insulating joint.

Existing insulation techniques have been vulnerable to damage in theharsh wellbore environments. Additionally, the insulation techniqueshave created problems in establishing proper mating between drillcollars. Often, the insulation prevents the torquing necessary to createa sufficient connection between the drill pipes. To overcome suchproblems, jam nuts and epoxys have been used between adjacent drillpipes in an attempt to generate the required connection. However, thereremains a need to provide improved insulation techniques to preventfailures in such gap systems. It would be desirable that such a systembe capable of performing under harsh wellbore conditions, providesignals with reduced attenuation and/or provide stronger signals capableof operating in a variety of conditions.

SUMMARY OF THE INVENTION

In an aspect, the present invention relates to a gap collar for anelectromagnetic communication unit of a downhole tool positioned in awellbore. The downhole tool communicates with a surface unit via anelectromagnetic field generated by the electromagnetic communicationunit. The gap collar includes a first collar having a first endconnector, a second collar having a second end connector matinglyconnectable to the first end connector, a non-conductive insulationcoating and a non-conductive insulation molding. The non-conductiveinsulation coating is disposed on the first end connector and/or secondend connector. The non-conductive insulation molding is positioned aboutan inner and/or outer surface of the collars and moldingly conforms tothe shape thereof.

In another aspect, the invention relates to a downhole electromagnetictelemetry unit for communication with a surface electromagneticcommunication unit. The downhole electromagnetic telemetry unit isdisposed in a downhole tool positioned in a wellbore. The downholeelectromagnetic telemetry unit includes a gap collar, electromagneticcircuitry and a non-conductive insulation molding. The gap collarincludes a first conductive collar, a second conductive collar and anon-conductive insulation coating therebetween. The electromagneticcircuitry is operatively connected to each conductive collar whereby anelectromagnetic field is generated. The non-conductive insulationmolding is positioned about an inner and/or outer surface of the collarsand moldingly conforms to the shape thereof.

In another aspect, the invention relates to a method of generating anelectromagnetic field from a downhole tool positioned in a wellbore. Thedownhole tool has electronic circuitry adapted to communicate with asurface unit via the electromagnetic field. The method includesproviding the downhole tool with a gap collar to house theelectromagnetic circuitry, moldingly conforming a non-conductiveinsulation molding about an inner and/or outer surface of the collarsand applying the electromagnetic field across the gap collar. The gapcollar includes a first and a second conductive collar matinglyconnected together with a non-conductive insulation coating therebetweento form a capacitive element. The insulation molding conforms to theshape of the drill collar(s).

In another aspect, the invention relates to a method of providingdownhole information to a surface unit. The wellbore is formed byadvancing a drilling tool into the earth. The method includespositioning a downhole tool in a wellbore, measuring downhole data usingsensors positioned in the downhole tool, storing the downhole data in amemory unit positioned in the downhole tool and transmitting at least aportion of the downhole data to the surface via the electromagneticfield. The downhole tool has an electromagnetic telemetry system adaptedto communicate via an electromagnetic field with the surface unit.

Finally, in yet another aspect, the invention relates to a gap collarfor an electromagnetic communication unit of a downhole tool positionedin a wellbore. The downhole tool communicates with a surface unit via anelectromagnetic field generated by the electromagnetic communicationunit. The gap collar includes a first collar having a first threaded endconnector, and a second collar having a second threaded end connectormatingly connectable to the first threaded end connector. The gap collarfurther includes a non-conductive insulation coating and anon-conductive insulation molding. The non-conductive insulation coatingis disposed on the first and/or second threaded end connector. Theinsulation coating is adapted to electrically insulate the first andsecond threaded end connectors. The non-conductive insulation molding ispositioned about an inner and/or outer surface of the collars. The firstand/or second threaded end connector is modified from a standardthreaded end connector to receive the non-conductive insulation coatingwhereby the contact area between the threaded connectors is increased.

The downhole tool is capable of being operated in memory mode, such asfor the purposes of making and storing geological, geophysical, orpetrophysical measurements (porosity, resistivity, gamma ray, formationdip, formation velocity, etc.); subsurface monitoring (subsidence, fluidmigration, formation pressure, etc); production testing and monitoring(drill stem testing, fluid flow rate, fluid pressure, etc.) The downholetool may be dropped, pumped, or conveyed into a well (or any subsurfacestructure such as a cave, salt dome, storage cavern, etc) by any deviceor means (such as slickline, wireline, drill pipe, coiled tubing, etc.)The downhole tool may be left in the well with no direct connection tothe device that conveyed it, or the tools may be moved continuously orfrom stationary point to point.

The data communication channels made available by the electromagneticcommunication unit enable the operator at the surface to selectivelycheck that the tool is functioning within its desired operating limits.It will also provide some amount of data that a customer could use tomake decisions and take actions in before the tools return to thesurface. It can provide a two-way communication channel so as to sendcommands to the tool and receive information back. These commands can beused, for example, to operate any portion of the tool. Such commands canbe used to turn the tool, or some portion of the tool (such as aminitron generator, etc) off or on, change the type of data beingacquired or transmitted, or change the sampling rate of the data beingacquired or transmitted. The memory mode downhole tool may provide arelatively low cost option with additional functionality of service.

A sub-assembly is formed to facilitate communication between upholeequipment and a downhole assembly in a hydrocarbon reservoir drillingsystem that features insulation layers positioned about anelectromagnetic communication unit to prevent electrical and structurecompromise. Specifically, the sub-assembly includes a first collarhaving a threaded end connector and a second collar having a threadedend connector matingly connectable to the threaded end connector of thefirst collar. An insulation coating, such as a ceramic coating, isdisposed on one of the first threaded end connector, the second threadedend connector and combinations thereof. The insulation coatingelectrically insulates the first and second threaded connectors.

A bearing is disposed between the first and second collars to providecontact between shoulders the first and second drill collars. Thebearing is configured to allow the first and second collar to be torquedtogether without compromising the electrical integrity of the insulationcoating. In this manner, the first and second threaded connectors, alongwith the insulation material, defines a capacitive element thatfacilitates communication between uphole equipment and downholeassemblies.

A sub-assembly may be used to facilitate communication between upholeequipment and a downhole assembly in a hydrocarbon reservoir drillingsystem. The method involves providing first and second collars, varyinggeometries of the first threaded end connector, defining variedgeometries, disposing an insulation coating on the varied geometriesdefining a coated end connector with a sufficient quantity of theinsulation coating being present to provide the coated end connectorwith a shape substantially complementary to the second threaded endconnector and coupling together the first and second end connectorsdefining a coupled section. Each of the collars has a threaded endconnector disposed thereon defining first and second threaded endconnectors, respectively.

Other aspects and advantages of the invention will be apparent from thefollowing description and the appended claims.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1A is a schematic illustration of an electromagnetic communicationsystem for a downhole drilling tool suspended from a rig and positionedin a wellbore;

FIG. 1B is a schematic illustration of an electromagnetic communicationsystem for a downhole wireline tool suspended from a rig and positionedin a wellbore;

FIG. 2 is a block diagram of the electronics of the electromagneticcommunication system of FIG. 1;

FIG. 3 is a longitudinal cross section of a portion of a downholedrilling tool of FIG. 1;

FIG. 4 is cross-section of a portion of a downhole drilling tool shownof FIG. 1 taken along line 4-4;

FIG. 5 is a detailed view of a portion of the downhole drilling tool ofFIG. 3 within circle 5, depicting the insulated connection of adjacentdrill collars;

FIG. 6A is a detail of a standard thread of a drill collar;

FIG. 6B is a detail of the standard thread of FIG. 6A with a raisedpeak;

FIG. 6C is a detail of the standard thread of FIG. 6A with a deepenedvalley; and

FIG. 6D is a detail of the modified thread of FIG. 6B or 6C with aninsulation coating disposed thereon.

DETAILED DESCRIPTION OF THE INVENTION

FIG. 1A depicts a downhole drilling tool 12 provided with a downholeelectromagnetic communication unit 18. The downhole tool 12 is suspendedfrom a rig 11 and into a wellbore 14. The downhole tool 12 is adapted todrill the wellbore 14. The downhole tool 12 is operatively connected tothe rig 11 via drill string 20 and includes a drill bit 16 at a lowerend thereof The drill string includes a plurality of drill collarsconnected to form the drill string. Two such adjacent drill collars 26and 27 house the electromagnetic communication unit 18. Variouscomponents, such as sensors 19, power unit 28, a memory unit 25,electromagnetic communication unit 18 as well as other components, arepositioned in one or more drill collars and enable the downhole tool toperform various downhole operations. The downhole electromagneticcommunication unit is operatively coupled, preferably via a wirelesscommunication link, to a surface electromagnetic communication unit 22for communication therebetween.

The downhole tool may optionally be provided with mud pulse, wired drillpipe or other communication links for transmission between the surfaceand the downhole tool. In cases where the communication link is inactiveor non-existent and the downhole tool is incapable of transmitting datato the surface, the downhole tool stores such data in the memory module25 in the downhole tool. In such cases of non-communication, the datamay be retrieved from the memory module by retrieving the tool to thesurface. Alternatively, the downhole electromagnetic communication unitmay be used to generate an electromagnetic field F receivable by thesurface unit 22. The electromagnetic field wirelessly transmits datacollected in the memory module 25 to the surface unit 22. By way ofexample, the electromagnetic communication unit may be used tocommunicate data to the surface when the tool is performing memory modelogging. The surface unit 22 is also adapted to generate anelectromagnetic field receivable by the electromagnetic unit 18.

FIG. 1B depicts a downhole tool 12 a disposable in the wellbore 14 forperforming various formation evaluation operations, such as testing andsampling. The downhole tool 12 a may include various components, such aspower, sample chambers, hydraulic units, probes, packers, anchors orother devices, such as those described in U.S. Pat. Nos. 4,936,139 and4,860,581, assigned to the assignee of the present invention. Suchcomponents may include sensors 19 a adapted to take various measurements(ie. pressure, temperature, and other downhole parameters), a powermodule 28 a, a memory module 25 a and telemetry modules 26 a and 27 a.

The downhole tool 12 a is suspended in the wellbore via a wireline cable24. The downhole tool may optionally be lowered to selected depths inthe wellbore via various conveyors, such as a slickline, drill pipe,coiled tubing or other known techniques. Such a connector may be wiredsuch that signals may pass between the surface and downhole tool toperform various operations and transmit data. The connector may beselectively deactivated, released, or reconnected as will be understoodby those of skill in the art.

Data collected by the downhole tool may be retrieved from the memorymodule upon retrieval of the tool to the surface, or by transmission viathe wireline cable for later use. In cases where the connector isdetached, deactivated or incapable of transmitting data to the surface,the downhole tool stores such data in a memory module 25 a in thedownhole tool. The data may be transmitted to the surface via anelectromagnetic communication 18 a positioned in telemetry modules 26 aand 27 a. The downhole electromagnetic communication unit 18 a may beused to generate an electromagnetic field Fa receivable by the surfaceunit 22. The electromagnetic field is capable of wirelessly transmittingdata collected in the memory module 25 a to the surface unit 22.

FIG. 2 depicts the communication between the surface and downholeelectromagnetic communication units of FIG. 1A. A wireless communicationlink 200 is established between the surface electromagneticcommunication unit 22 and the downhole electromagnetic communicationunit 18. Data collected via a sensors 19 is stored in memory 25. Thesensors and/or memory may be separate from, or integral with, thedownhole electromagnetic communication unit. The data is processed viaprocessor 212 and transmitted to the surface via transceiver 210. Thetransceiver 210 is also adapted to receive signals from and transmitssignals to the surface electromagnetic communication unit 22.

The surface unit 22 includes a transceiver 202, a processor 204 and arecorder 208. The transceiver 202 receives signals from and transmitssignals to the downhole electromagnetic communication unit 18. Thedownhole data is received by the uphole transceiver and sent to theprogrammable processor 204 for processing. The data is then recorded inthe recorder 208. A synchronized clock may optionally be coupled to thesurface and/or downhole units for synchronization of the electromagneticsystem.

Communication link 200 is created by the electromagnetic field Fgenerated by the surface unit 22 and/or the downhole unit 18. The FieldF is used as a wireless coupling for the passage of signals between thesurface and downhole units.

FIGS. 3 and 4 depict in greater detail a portion of the downhole tool 12incorporating the downhole electromagnetic communication unit 18 of FIG.1A. FIG. 3 is a longitudinal cross section of the downhole tooldepicting a gap collar 403, upper drill collar 26 and lower collar 27.FIG. 4 is a horizontal cross-sectional view of the downhole tool 12 ofFIG. 3 taken along line 4-4.

The upper and lower drill collars 26 and 27 have a passage 401 thereinto allow the flow of mud there through. The collars are preferablythreadably connected together to form a joint 402. Other connections mayalso be used, such as heat shrink connectors. An insulation coating 400is disposed between the drill collars at the joint to provide contactand insulation therebetween. The insulation coating 400 is preferably inpowdered form and sprayed onto the threads. The insulation coating isalso preferably, for example, a ceramic, such as aluminum oxide.

A metal ring or bearing 418 may be disposed between upper drill collar26 and lower drill collar 27 to facilitate contact therebetween. As willbe described further herein, the insulation coating 400 may interferewith the proper mating of the adjacent drill collars. To assure properelectrical and/or mechanical connection, a metal bearing may be insertedbetween the drill collars.

An inner sleeve 419 may also be provided along the inner surface of themated drill collars. Preferably, inner sleeve 419 extends across joint419 to provide an additional layer of protection. This may be usefulduring assembly to protect the insulation coating 400 disposed betweenthe drill collars. The inner sleeve is preferably a non-conductivematerial, such as plastic, that may be similar to the material used forthe protective layer 412. The non-conductive material may further assistin enhancing the signal by further magnifying the overall gap betweenthe drill collars.

Mandrel 404 is positioned in the passage 401 and extends through thedownhole tool 12. The mandrel is typically positioned symmetricallyabout an axis A of the downhole tool 12. The mandrel 404 is supported inthe downhole tool at a downhole position via lower electromagneticassembly 406 and an uphole position via upper electromagnetic assembly407. The upper and lower electromagnetic assemblies are typically ofopposite polarity with a gap (not shown) therebetween. The gap istypically embedded within the mandrel between the upper and lower drillcollars. The gap collar is used to extend the resistance generated bythe electromagnetic communication over a greater distance, and/or toenhance the electrical connection between the mandrel and the drillcollars.

A mandrel insulation layer 408 is disposed about mandrel 404.Preferably, the mandrel insulation layer 408 is molded about the mandrel404 to provide a hydraulic seal thereabout. An inner molded insulationlayer 410 is disposed inside passage 401 along the inner surface of thedrill collars. An outer molded insulation layer 411 is disposed aboutthe outer surface of the drill collars. Preferably, the inner and outermolded insulation layers are molded to the surface of the drill collarsto provide a hydraulic seal. Because drill collars 26 and 27 are betweeninsulation layers 410 and 411, a seal is created about the drill collarsand join 402.

The insulation layers 408, 410 and 411 are preferably made of anelastomeric, or rubber, and non-conductive material adapted to provide ahydraulic seal. The material is moldable so that it may conform to theshape of the adjacent component (ie. the mandrell or the drill collars).An example of a usable rubber that may be used is a nitril rubber.

A protective layer 412 is disposed about the outer insulation layer 411.Preferably, the protective layer and/or outer insulation layer extendsacross drill collars 26 and 27 to provide a protective sealabout joint402. Protective layer 412 may be a sleeve extending along upper drillcollar 26 and lower drill collar 27, and surrounding insulation layer411. The protective layer is preferably a non-conductive material thatprovides a hardened surface to protect the underlying insulation layer.Such materials may include, for example, plastics, hardened elastomers,fiberglass and other materials capable of providing additionalprotection to the insulation layer.

The communication unit 18 may also be provided with additionalprotectors, such as wear bands 420. Wear bands 420 are positioned aboutthe drill collars 26 and 27 and may or may not overlap layer 412. Thewear bands are preferably hardened metal surfaces adapted to receive themajor impact of forces applied to downhole electromagnetic communicationunit. The wear bands preferably provide a raised contact surface, orstandoff, to further protect the outer surface of the downholecommunication unit. In other words, the distance from axis A to an outersurface of the wear band is preferably greater than the distance fromaxis A to the outer surface of the drill collars, outer layer 411 and/orprotective layer 412 (if present). This provides an initial point ofcontact for the drilling tool as it passes through the wellbore.

The layers, coatings and other protectors may be also used to ensurethat the mechanical and electrical properties of capacitive element 500are not compromised by the operating environment. For example,insulation layers 408, 410 and 411 are used to establish a hydraulicseal to minimize resistance loss and/or prevent exposure of moisture orwater to the electromagnetic communication unit. Additionally, theinsulation may extend the length of capacitive element 500 to improvethe signal generated by the downhole communication unit 18.

The nonconductive components, such as the layers, coatings, seals andprotectors, also create a non-conductive gap between the conductivedrill collars 26 and 27. This non-conductive gap is used to assists ingenerating and/or magnifying the electromagnetic signal. FIG. 5 is ablowup of the portion of the downhole tool 12 in circle 5 of FIG. 3.FIG. 5 shows a detailed view of the connection between drill collars 26and 27 at joint 420. The male portion of drill collar 26 is threadablyconnected via male threads 502 to the female portion of adjacent drillcollar 27 and its corresponding, mated female threads 504. Bearing 418is disposed between shoulder 508 of upper drill collar 26 and shoulder510 of lower drill collar 27.

Upper drill collar 26 and lower drill collar 27 are threaded together,with insulation coating 400 disposed therebetween. Insulation coating400 is disposed upon male threads 502, as well as the shoulder surface508 extending from the male threads to the outer surface of upper drillcollar 26. As shown in FIG. 5, the insulation coating is disposed alongthe male threads and shoulder of drill collar 26. However, theinsulation coating may be applied to the thread and/or shoulder portionsof drill collar 26 and/or drill collar 27.

The male and female threads are preferably standard American PetroleumInstitute (API) threads. However, the insulation may have a thicknessthat contributes to interference with the proper mating of the threadsand the proper contact between the shoulders of the adjacent drillcollars. To provide the desired connection, the threads (male only,female only or both) may need to be adjusted for the application andintervening presence of the insulation material between mated threads.

FIGS. 6A-6D depict an example of the dimensions of a standard thread andits adjustment for the application of insulation material thereon. FIG.6A depicts a standard API thread 601, such as the male thread 502 ofFIG. 5, before the application of insulation and/or modification. Themale thread has peaks 600 and valleys 602 with slopes 604 therebetween.The distance between the peaks 600 and valleys 602 is referred to as theinitial height h₁.

FIG. 6B depicts a modified thread 601′. The shape of thread 601′ ismodified from the initial shape of thread 601 for the application of aninsulation coating. In this case, the peaks 600 of the threads areincreased to an extended peak 600′. The resulting height between thehigher peaks 600′ and valleys 602 is a new, increased height h₂.

FIG. 6C depicts an alternate modified thread 601″. The shape of thread601′ is modified from the initial shape of thread 601 for theapplication of an insulation coating. In this case, the valleys 602 ofthe threads are deepened to a to a deeper valley 602′. The resultingheight between the deeper valleys 602′ and valleys 602 is new, increasedheight h₂. The valleys 602 may be deepened and/or the slopes 604 may beadjusted. A variety of geometries are envisioned for the male and/orfemale threads forming the threaded joint.

As shown in FIG. 6D, modified thread 601′ has been coated withinsulation coating 605. The insulation coating is preferably appliedwith sufficient thickness to obtain the desired overall dimension of thecombined thread and insulation. In this case, the overall combineddimension of the modified thread and insulation coating 605 is nowadapted to mate with a corresponding API thread. The modified thread601′″ could also be generated using modified thread 601″ of FIG. 6B.

The thread may be fabricated so that after application of insulationcoating 400, the threads with the attached insulation coating define ageometry that is complimentary to mated threads. For example, wherethreads 601′″ define a male API thread, such as male threads 502 of FIG.5, they are compatible with female API threads, such as the femalethreads 504 of FIG. 5. To that end, the threads are typically formed byvarying dimensions of a standard (API) thread. The dimensions of thethread and insulation coating combination are preferably adapted to matewith the standard API thread dimensions.

As shown in FIG. 6D, the insulation coating 400, may be provided with athickness c₁ on protrusions, a thickness c₂ on recesses and/or athickness c₃ on portions therebetween. Thickness c₁ may be substantiallythe same as thickness c₂ and/or c₃. In a further embodiment, thicknessc₁ may differ from thickness c₂ and/or c₃.

The threads are preferably modified to prevent the insulation coatingfrom reducing the contact area between the male and female threads. Thethreads may be modified such that the stress concentration, or force perunit area, on the insulation coating is reduced below the forcesinvolved with coated standard (non-modified) threads.

Referring back to FIG. 5, the upper and lower drill collars with theinsulation coating therebetween define a capacitive element 500. Thecapacitive element assists in creating the electromagnetic field usedfor communication between the surface and the downhole communicationunits. The upper drill collar 26 and lower collar 27 are said to beelectrically and mechanically coupled together.

The male threads 502 have been modified and insulation coating 400applied thereto. Preferably, threads 502 are modified prior to thereceipt of insulation coating 400 such that the resulting contact areabetween male thread 502 and female thread 504 is increased. Theincreased contact area of the male and female threads assists inreducing stress concentrations within capacitive element 500. Theincreased contact area is also used to increase the structural integrityof capacitive element 500 by reducing the probability of structuralcompromise of insulation coating 400 during coupling of male thread andfemale thread.

The coupling, often referred to as torquing, of the drill collars candamage the insulation coating 400 if too great, but prevent sufficientelectrical contact if too little. Additionally, there is preferablysufficient torque applied to insure the mechanical integrity of thejoint and prevent mechanical or electrical failure of the system. Thetorque is preferably comparable to the torque applied to other drillcollars in a drill string. It is desirable that the threads andinsulation permit the drill collars to be connected such that the torqueapplied to the drill collars is about at least as great as the otherdrill collar connections in the remainder of the drill string, typicallyan average of the torque applied to the remainder of the drill collars.To provide the necessary contact without damage, the contact area isadjusted to distribute the load across the threads and reduce thelikelihood of damage to insulation coating 400. Damage to insulationcoating 400 may affect the mechanical and electrical integrity ofcapacitive element 500, which may result in an electrical short betweenmale and female threads. This may, in turn, lead to a drastic reductionin the amplitude of the transmitted signal.

Preferably, the stress concentration applied to capacitive element 500is limited to a level that is below a maximum stress concentrationlevel. The maximum stress concentration level is defined as that stressconcentration level that will cause a compromise of a structuralintegrity of capacitive element 500. By having a stress concentrationwithin capacitive element 500 that is less than a maximum stressconcentration, application of substantially the same amount of torquethat is applied to downhole assembly 12, shown in FIG. 1A, is applied tocapacitive element 500. This provides direct torquing of first collar 26and second collar 27.

Upon coupling together the upper and lower drill collars, male threads502 and female threads 504 are mated together. Male threads 502 andfemale threads 504 define the plates of capacitive element 500, andinsulation coating 400 defines the dielectric. Capacitive element 500may be employed to facilitate communication, for example, by modulatingthe applied voltage transmission of signals. The frequency of thevoltage applied is a function of choice of design and determined in partby the impedance of capacitive element, as defined by, inter alia, ofthe contact area between male thread 502 and female thread 504, as wellas the dielectric constant insulation coating 400 and thickness thereof.At frequencies lower than a few hundred Hertz the impedance of thecapacitive element will be dominated by its resistivity, which in turnwill be dominated by the amount of moisture remaining in the capacitiveelement. In a preferred embodiment, heat would be applied to thecapacitive element to remove as much moisture as possible and then thedielectric material would be sealed with epoxy to disallow moisture fromrepenetrating the dielectric.

The dimensions of male thread 502 and insulation coating 400 may resultin spaces, voids and/or other cavities between upper drill collar 26 andlower drill collar 27. It may be required to fill some of these voidsand cavities to maintain the structural integrity of capacitive element500 during operation. For example, a cavity 512 may be present betweenmale and female threads 502 and 504. To prevent structural compromise ofinsulation coating 400 due, for example, to expansion of gases that maybe trapped therein, epoxy or some other suitable material may beinjected therein. In this fashion, the gases, or other material, thatmay undergo volumetric changes when subjected to the downholeenvironment are removed. The solidification of an epoxy within thecavities also increases the structural rigidity of the device whensolidified and helps keep any moisture out of any cavities within thedielectric.

In another example, upon coupling together or upper drill collar 26 andlower drill collar 27, shoulders 508 and 510 may not meet. To providethe desired contact between the shoulders, metal ring or bearing 418 maybe inserted. The bearing 418 is positioned such that additional contactis made between the adjacent drill collars and the structural integrityof the capacitive element 500 is increased. Bearing 418 is alsopositioned to prevent flexing of upper drill collar 26 relative to lowerdrill collar 27, and to prevent added stress concentrations oninsulation coating 400 beyond the maximum stress concentration. Thisbearing also provides an additional seal about the drill collars.

Bearing 418 is configured and dimensioned accordingly to reduce stressconcentration resulting from non-contact between the drill collarshoulders. To that end, bearing 418 dimensions are preferablyestablished based upon the thicknesses c₁ and c₂ of the insulationcoating (FIG. 6D). Bearing 418 is then slid on first collar 26 beforetorquing of first and second collars together. The collars arepreferably torqued together with sufficient force that the mechanicalintegrity of the collar is maintained, that force being less than thatwhich would cause mechanical failure of the insulating coating on thethread.

In operation, sensors 19 in downhole tool 12 are employed to obtain aplurality of downhole measurements regarding formation and wellboreproperties surrounding downhole assembly 12. Such measurements mayinclude, for example, geological, geophysical, or petrophysicalmeasurements such as porosity, resistivity, gamma ray, formation dip,and formation velocity; subsurface measurements such as subsidence,fluid migration, and formation pressure; or production testing andmonitoring measurements such as drill stem testing, fluid flow rate, andfluid pressure. The measurement data is stored in memory 14. A commandfrom the surface unit 22 is sent downhole. The command is received bythe transceiver 210 in the downhole electromagnetic communication unit18. the downhole electromagnetic communication unit generates a magneticfield by electrical communication between mandrel 404 and second collar27. This electrical communication allows application of a voltage acrosscapacitive element 500.

Upon completion of obtaining such data measurements by sensors 19, thedata measurements are stored in memory 28, wherein memory 28 is coupledto downhole communication unit 18. Thus, memory mode logging is enabledand employed in downhole assembly 12.

The downhole communication unit 18 is in communication with surface unit22. The measurements stored in memory 38 are sent from downholeelectromagnetic communication unit 18 to the surface via electromagneticfield. The electromagnetic field is injected into the formationsurrounding downhole assembly 12 wherein the electromagnetic fieldpropagates to surface unit 22.

Surface unit 22, as mentioned above, receives information from downholeelectromagnetic unit 18, typically sent in subsets of the informationstored in memory 25. Once surface unit 22 receives such information, aview of conditions about downhole tool 12 can be acquired. This view canallow decisions to be determined regarding operation of the wellboresystem.

Commands can then be sent downhole to downhole electromagneticcommunication unit 18 via surface unit 22. These commands can include,but are not limited to, activating downhole operations, discontinuationof downhole operations, controlling the types of measurements beingacquired or transmitted and changing the sampling rate of themeasurements being acquired or transmitted.

While FIGS. 3 through 6 refer to drill collars, it will be appreciatedthat the drill collars may be collars or modules, such as thosethreadably assembled to form downhole communication unit of FIG. 1B, orother downhole evaluation tools (ie. wireline, slickline, drill stemtest or coiled tubing tools). The components in such cases will besubstantially the same, except that they may not contain a passagetherethrough to permit mud flow through the tool. Additionalnon-conductive insulation may or may not be provided along innersurfaces of the collars or about internal mandrels if present within theevaluation tool.

While this invention has been described with references to variousillustrative embodiments, the description is not intended to beconstrued in a limiting sense. Various modifications and combinations ofthe illustrative embodiments, as well as other embodiments of theinvention, will be apparent to persons skilled in the art upon referenceto the description. It is, therefore, intended that the appended claimsencompass any such modifications or embodiments.

1. A method of providing downhole information from a downhole evaluation tool located in a wellbore to a surface unit, the wellbore formed by advancing a drilling tool into the earth, the method comprising: positioning the downhole evaluation tool in the wellbore, the downhole evaluation tool having an electromagnetic telemetry system adapted to communicate via an electromagnetic field with the surface unit, wherein the electromagnetic telemetry system comprises a pair of collars matingly connected with a non-conductive insulation coating therebetween, the non-conductive insulating coating defining a gap, and wherein the electromagnetic telemetry system further comprises a non-conductive insulation member extending across the gap about one of an inner surface of the collars, an outer surface of the collars and combinations thereof, the insulation member conforming to the shape thereof; measuring downhole data using sensors positioned in the downhole tool; storing the downhole data in a memory unit positioned in the downhole tool; and transmitting at least a portion of the downhole data to the surface via the electromagnetic field.
 2. The method of claim 1 wherein the downhole tool is one of a wireline tool, a slickline tool, a coiled tubing tool and combinations thereof.
 3. The method of claim 1 wherein the collars have connectors with mated threads, the method further comprising modifying the threads of at least one of the collars for receipt of the non-conductive insulation coating.
 4. The method of claim 1 further comprising processing the downhole data to determine a course of action.
 5. The method of claim 1 further comprising transmitting commands from the surface unit to the downhole unit for execution thereof.
 6. The method of claim 5, wherein transmitting commands from the surface unit to the downhole unit comprises transmitting a command to change the power level of the electromagnetic field.
 7. The method of claim 5, wherein transmitting commands from the surface unit to the downhole unit comprises transmitting a command to change a type of the downhole data transmitted to the surface.
 8. The method of claim 5, wherein transmitting commands from the surface unit to the downhole unit comprises transmitting a command to change a sampling rate of measuring downhole data.
 9. The method of claim 5, wherein transmitting commands from the surface unit to the downhole unit comprises transmitting a command to change the baud rate of the data transmission.
 10. A method of constructing a downhole tool, comprising: providing an upper collar member; providing a lower collar member; applying a non-conductive insulating coating to one of a connector on the upper collar member, a connector on the lower collar member and combinations thereof; connecting the upper collar member to the lower collar member such that the non-conductive insulating coating defines a gap; and applying a non-conductive insulating member about one of the inner surface of the upper and lower collar members, the outer surface of the upper and lower collar members, and combinations thereof, wherein the non-conductive insulating member extends across the gap.
 11. The method of claim 10, wherein applying a non-conductive insulating member comprises applying a non-conductive insulating molding.
 12. The method of claim 10, further comprising disposing a bearing between a shoulder of the upper collar member and a shoulder of the lower collar member.
 13. The method of claim 12, wherein disposing a bearing between the shoulder of the upper collar member and the shoulder of the lower collar member comprises disposing a metal ring between the shoulder of the upper collar member and the shoulder of the lower collar member.
 14. The method of claim 11, further comprising disposing a non-conductive sleeve along the inner surface of upper and lower collar members, extending across the gap.
 15. A gap collar for an electromagnetic communication unit of a downhole tool positioned in a wellbore, comprising: a first collar having a first end connector; a second collar having a second end connector matingly connected to the first end connector; a non-conductive insulating coating electrically insulating the first end connector from the second end connector, the non-conductive insulating defining a gap; means for insulating the outer surface of the first and second collar extending across the gap about one of an inner surface of the collars, an outer surface of the collars and combinations thereof, the insulation member conforming to the shape thereof. 